Submitted by Automa??o e Estat?stica (sst@bczm.ufrn.br) on 2016-08-16T22:25:59Z No. of bitstreams: 1 GilmarAlexandreGuedesJunior_DISSERT.pdf: 5929995 bytes, checksum: a36bb4fc00b8498bf0fbb8727e65d0ec (MD5) / Approved for entry into archive by Arlan Eloi Leite Silva (eloihistoriador@yahoo.com.br) on 2016-08-23T21:46:54Z (GMT) No. of bitstreams: 1 GilmarAlexandreGuedesJunior_DISSERT.pdf: 5929995 bytes, checksum: a36bb4fc00b8498bf0fbb8727e65d0ec (MD5) / Made available in DSpace on 2016-08-23T21:46:54Z (GMT). No. of bitstreams: 1 GilmarAlexandreGuedesJunior_DISSERT.pdf: 5929995 bytes, checksum: a36bb4fc00b8498bf0fbb8727e65d0ec (MD5) Previous issue date: 2016-04-29 / A prov?ncia pr?-sal ? composta por grandes acumula??es de ?leo leve, de excelente qualidade e com alto valor comercial, uma realidade que coloca o Brasil em uma posi??o estrat?gica frente ? grande demanda de energia mundial. Nessa prov?ncia encontram-se as maiores descobertas realizadas no mundo nos ?ltimos dez anos; as ?reas de Libra, de Franco e o Campo de Lula, todas com volumes superiores a 8 bilh?es de barris de ?leo recuper?veis. Para desenvolver e otimizar a produ??o desses campos, foi feito um estudo para escolha dos m?todos de recupera??o avan?ada, tendo como principais motiva??es a presen?a do di?xido de carbono (CO2) como contaminante e a decis?o estrat?gica de n?o o descartar, combinada ? alta RGO (raz?o g?s-?leo) do fluido do reservat?rio. O m?todo deveria tirar vantagem dos ?nicos recursos abundantes: a ?gua do mar e o g?s produzido. Dessa maneira, o processo de combinar esses recursos na inje??o alternada de ?gua e g?s (WAG) passou a ser visto como uma boa op??o. Nessa disserta??o, foi desenvolvido um modelo de reservat?rio com caracter?sticas do pr?-sal brasileiro, sendo aplicado o m?todo de recupera??o avan?ada de inje??o alternada de ?gua e g?s. O potencial de produ??o desse reservat?rio foi analisado por meio de par?metros como: fluido que inicia o processo de inje??o, posi??o das completa??es dos po?os injetores, bem como vaz?es de inje??o de ?gua e de g?s e o tempo de ciclo de cada fluido injetado. Os resultados mostraram um bom desempenho do m?todo WAG-CO2 misc?vel, com ganhos de at? 26% no FR com rela??o a recupera??o prim?ria, j? a aplica??o da inje??o de ?gua e de g?s, de maneira individual, n?o foi capaz de superar o patamar de 10% de ganho. O par?metro de maior influ?ncia nos resultados foi o tempo de ciclo, com maiores valores de FR obtidos com a utiliza??o dos menores tempos. / The pre-salt province is composed by large amounts of light oil and with good quality, a reality that puts Brazil in a strategic position facing the great demand for energy worldwide. In this province are the largest discoveries in the world in the last ten years; areas as Libra, Franco and Lula field, everyone containing volumes greater than 8 billion recoverable oil barrels. To develop and optimize the production of these fields, a study was done for choosing the improved oil recovery methods. The main motivations were the presence of carbon dioxide (CO2) as a contaminant and the strategic decision of do not discard it, combined with high GOR (gas-oil ratio) of the reservoir fluid. The method should take advantage of the unique abundant resources: seawater and produced gas. This way, the process of matching these resources in the water alterning gas injection (WAG) became a good option. In this master?s dissertation, it was developed a reservoir model with average characteristics of the Brazilian pre-salt, where was applied the improved oil recovery method of water alternating gas. The production of this reservoir was analyzed by parameters as: the first fluid injected in the injection process, position of the injection wells completion, injection water and gas rate and cycle time. The results showed a good performance of the method, with up to 26% of gains in the recovery factor regarding the primary recovery, since the application of water injection and gas, individually, was not able to overcome 10 % of gain. The most influential parameter found in the results was the cycle time, with higher recovery factor values obtained with the use of shorter times.

Made available in DSpace on 2014-12-17T14:08:47Z (GMT). No. of bitstreams: 1 MartinhoQAF_DISSERT.pdf: 3517855 bytes, checksum: e2d79876500fdde55b949a6a832b6ff0 (MD5) Previous issue date: 2011-05-27 / Water injection is the most widely used method for supplementary recovery in many oil fields due to various reasons, like the fact that water is an effective displacing agent of low viscosity oils, the water injection projects are relatively simple to establish and the water availability at a relatively low cost. For design of water injection projects is necessary to do reservoir studies in order to define the various parameters needed to increase the effectiveness of the method. For this kind of study can be used several mathematical models classified into two general categories: analytical or numerical. The present work aims to do a comparative analysis between the results presented by flow lines simulator and conventional finite differences simulator; both types of simulators are based on numerical methods designed to model light oil reservoirs subjected to water injection. Therefore, it was defined two reservoir models: the first one was a heterogeneous model whose petrophysical properties vary along the reservoir and the other one was created using average petrophysical properties obtained from the first model. Comparisons were done considering that the results of these two models were always in the same operational conditions. Then some rock and fluid parameters have been changed in both models and again the results were compared. From the factorial design, that was done to study the sensitivity analysis of reservoir parameters, a few cases were chosen to study the role of water injection rate and the vertical position of wells perforations in production forecast. It was observed that the results from the two simulators are quite similar in most of the cases; differences were found only in those cases where there was an increase in gas solubility ratio of the model. Thus, it was concluded that in flow simulation of reservoirs analogous of those now studied, mainly when the gas solubility ratio is low, the conventional finite differences simulator may be replaced by flow lines simulator the production forecast is compatible but the computational processing time is lower. / A inje??o de ?gua ? o m?todo de recupera??o suplementar mais difundido na maioria dos campos de petr?leo, devido a v?rios motivos, como o fato de a ?gua ser um eficiente agente deslocante de ?leos com baixa viscosidade associado ao fato de ser relativamente f?cil de injetar e de existir grande disponibilidade de ?gua a um custo relativamente baixo de se obter. Para o dimensionamento de um projeto de inje??o de ?gua ? necess?rio efetuar um estudo de reservat?rio com o objetivo de se definir os v?rios par?metros necess?rios para aumentar a efic?cia do m?todo. Para este estudo podem ser utilizados v?rios modelos matem?ticos classificados como anal?ticos ou num?ricos. Este trabalho tem como objetivo efetuar uma an?lise comparativa entre os resultados apresentados por um simulador de linhas de fluxo e um simulador convencional por diferen?a finita, que s?o dois tipos de simuladores de fluxo baseados em m?todos num?ricos, para um modelo de um reservat?rio de petr?leo leve submetido ? inje??o de ?gua. Para tanto foram montados dois modelos de reservat?rio, sendo um modelo heterog?neo e outro homog?neo contendo valores m?dios das propriedades de rocha do primeiro modelo. Foram realizadas compara??es dos resultados destes modelos considerando sempre as mesmas condi??es de opera??o. Em seguida foram alterados alguns par?metros de fluido e de rocha em ambos os modelos e efetuadas novamente compara??es de resultados. A partir do planejamento fatorial, realizado para a an?lise de sensibilidade dos par?metros de reservat?rio, foram escolhidos alguns casos para efetuar an?lise da varia??o dos par?metros operacionais escolhidos que foram a vaz?o de inje??o de ?gua e a localiza??o dos canhoneados. Observou-se que os resultados entre os simuladores s?o bastante similares na maioria dos casos estudados, tendo sido encontrado diverg?ncias apenas nos casos em que h? aumento na raz?o de solubilidade de g?s do modelo. Desta maneira foi conclu?do que o simulador convencional por diferen?as finitas pode ser substitu?do por um simulador por linhas de fluxo em reservat?rios semelhantes ao estudado, quando a raz?o de solubilidade possui valores baixos, sem preju?zo aos resultados de produ??o e com menores tempos de processamento computacional. / 2020-01-01

Made available in DSpace on 2014-12-17T15:01:45Z (GMT). No. of bitstreams: 1 JennysLMB.pdf: 3002293 bytes, checksum: 3b71773a14bee418fd80243a633d0cc8 (MD5) Previous issue date: 2008-02-22 / Steam assisted gravity drainage process (SAGD) involves two parallel horizontal wells located in a same vertical plane, where the top well is used as steam injector and the bottom well as producer. The dominant force in this process is gravitational. This improved oil recovery method has been demonstrated to be economically viable in commercial projects of oil recovery for heavy and extra heavy oil, but it is not yet implemented in Brazil. The study of this technology in reservoirs with characteristics of regional basins is necessary in order to analyze if this process can be used, minimizing the steam rate demand and improving the process profitability. In this study, a homogeneous reservoir was modeled with characteristics of Brazilian Northeast reservoirs. Simulations were accomplished with STARS , a commercial software from Computer Modelling Group, which is used to simulate improved oil recovery process in oil reservoirs. In this work, a steam optimization was accomplished in reservoirs with different physical characteristics and in different cases, through a technical-economic analysis. It was also studied a semi-continuous steam injection or with injection stops. Results showed that it is possible to use a simplified equation of the net present value, which incorporates earnings and expenses on oil production and expenses in steam requirement, in order to optimize steam rate and obtaining a higher net present value in the process. It was observed that SAGD process can be or not profitable depending on reservoirs characteristics. It was also obtained that steam demand can still be reduced injecting in a non continuous form, alternating steam injection with stops at several time intervals. The optimization of these intervals allowed to minimize heat losses and to improve oil recovery / O processo de drenagem gravitacional com inje??o cont?nua de vapor (SAGD) envolve dois po?os horizontais paralelos localizados em uma mesma vertical, onde o po?o superior ? usado como injetor de vapor e o inferior como produtor. A for?a dominante neste processo ? a gravitacional. Este m?todo de recupera??o avan?ada tem sido demonstrado ser economicamente vi?vel em projetos comerciais de recupera??o de petr?leo pesado e extra pesado, mas ainda n?o foi implementado no Brasil. O estudo desta tecnologia em reservat?rios com caracter?sticas das bacias regionais ? necess?rio para analisar como se ad?qua o processo para minimizar a demanda de vapor obtendo a maior rentabilidade do processo. Neste estudo foi usado um modelo homog?neo com caracter?sticas de reservat?rios do Nordeste Brasileiro. As simula??es foram realizadas em um programa comercial da Computer Modelling Group , o STARS , m?dulo usado para realizar estudos de m?todos de recupera??o avan?ada de reservat?rios de ?leo. Neste trabalho, foi realizada uma otimiza??o do vapor em reservat?rios com diferentes caracter?sticas f?sicas e em diferentes cen?rios, atrav?s de uma an?lise t?cnico-econ?mica. Tamb?m foi estudada a inje??o de vapor semi-cont?nua ou com paradas. Os resultados obtidos mostraram que ? poss?vel utilizar uma equa??o simplificada do valor presente l?quido, que incorpora os ganhos e gastos na produ??o de ?leo e os gastos na inje??o de vapor, para otimizar a demanda do vapor obtendo um maior valor presente l?quido no processo. Observou-se que o m?todo (SAGD) pode ser ou n?o rent?vel dependendo das caracter?sticas do reservat?rio. Encontrou-se tamb?m que a necessidade de vapor pode ainda ser diminu?da utilizando esquemas de inje??o de vapor com paradas em intervalos de tempo otimizados, e isto permitiu minimizar as perdas de calor e melhorar a recupera??o.

Submitted by Automa??o e Estat?stica (sst@bczm.ufrn.br) on 2017-01-13T12:25:48Z No. of bitstreams: 1 MarcelAraujoRocha_DISSERT.pdf: 5011334 bytes, checksum: d4996c7516aeda7455db92bc1ebfc1d5 (MD5) / Approved for entry into archive by Arlan Eloi Leite Silva (eloihistoriador@yahoo.com.br) on 2017-01-23T13:23:05Z (GMT) No. of bitstreams: 1 MarcelAraujoRocha_DISSERT.pdf: 5011334 bytes, checksum: d4996c7516aeda7455db92bc1ebfc1d5 (MD5) / Made available in DSpace on 2017-01-23T13:23:05Z (GMT). No. of bitstreams: 1 MarcelAraujoRocha_DISSERT.pdf: 5011334 bytes, checksum: d4996c7516aeda7455db92bc1ebfc1d5 (MD5) Previous issue date: 2016-03-14 / A explora??o de reservas de hidrocarbonetos pesados e extrapesados ? de interesse primordial para muitas companhias de petr?leo, uma vez que, a magnitude desses recursos representa parte da energia mundial. A produ??o de ?leo pesado, a partir de dep?sitos subterr?neos, ? complexa, at? mesmo sob as melhores circunst?ncias, devido principalmente ? elevada viscosidade do ?leo. Para melhor desenvolver o processo de produ??o, tornando-o eficiente, de maneira que os fluidos que n?o seriam produzidos consigam chegar ? superf?cie, foram desenvolvidos m?todos de recupera??o convencionais e especiais, para obten??o de um maior fator de recupera??o e, consequentemente, uma maior lucratividade na opera??o de explota??o dessas jazidas. Para reduzir a alta viscosidade e as elevadas tens?es interfaciais, foram desenvolvidos os m?todos t?rmicos. Nesse trabalho, simulou-se a inje??o continua de vapor, com po?os injetores verticais e horizontais, para desenvolver um reservat?rio com caracter?sticas do Nordeste brasileiro, de ?leo pesado, atrav?s da condu??o dos fluidos produzidos com po?o horizontal. Foram feitas an?lises t?cnicas e econ?micas dos modelos que diferiam quanto ?s suas restri??es e arranjos estruturais do sistema. Na configura??o horizontal se observou a influ?ncia da vaz?o de inje??o, da dist?ncia vertical e da dist?ncia lateral sobre o fator de recupera??o. Na configura??o vertical se analisou a influ?ncia da vaz?o de inje??o, da completa??o dos injetores, da dist?ncia lateral e da quantidade de po?os injetores sobre o fator de recupera??o. Diante dos modelos proposto, analisou-se a produ??o acumulada de ?leo, o Volume Poroso Injetado, a forma??o das c?maras de vapor e o Valor Presente L?quido. Tecnicamente, os modelos em que se injetou vapor com po?os verticais obtiveram maior fator de recupera??o de ?leo, j? os modelos horizontais se sobressa?ram economicamente. / The reserves exploration of heavy and extra heavy hydrocarbon is of prime interest to many oil companies, since the magnitude of these resources the magnitude of these resources still stands out on the global and Brazilian energy matrix. The production of heavy oil, from the underground deposits is complex, even on the best of circumstances, mainly due to the high viscosity of the oil. To further develop the process of production, making it efficient, so that the fluids that would not be produced get to reach the surface, complementary recovery methods and advanced were developed to obtain a higher recovery factor and, hence, greater profitability in operation exploitation of these deposits. To combat the high viscosity and high interfacial tensions, thermal methods were developed. In this work, the steam injection continues was simulated in vertical and horizontal injection wells, to develop a reservoir with characteristics of the Brazilian Northeast of heavy oil, by conducting fluid produced with horizontal well. Technical and economic analyzes were made of the models that differ in their structural constraints and system arrangements. In horizontal configuration was observed the influence of the injection flow, of the vertical distance and of the lateral distance over the recovery factor. In vertical configuration was analyzed the influence of the injection flow, of the injection wells completion, of the lateral distance and the amount of injection wells over the recovery factor. Faced the proposed models, was analyzed the cumulative oil production, the Pore Volume Injected, the formation of steam chambers and the Net Present Value. Technically, the models in which steam is injected with vertical wells had higher recovery factor of oil, since the horizontal models stood out economically.

Made available in DSpace on 2014-12-17T15:47:50Z (GMT). No. of bitstreams: 1 BrunoCO.pdf: 708202 bytes, checksum: 3eb4368a0c268064bcd6ad892e1f2c0c (MD5) Previous issue date: 2009-05-22 / The constant increase of complexity in computer applications demands the development of more powerful hardware support for them. With processor's operational frequency reaching its limit, the most viable solution is the use of parallelism. Based on parallelism techniques and the progressive growth in the capacity of transistors integration in a single chip is the concept of MPSoCs (Multi-Processor System-on-Chip). MPSoCs will eventually become a cheaper and faster alternative to supercomputers and clusters, and applications developed for these high performance systems will migrate to computers equipped with MP-SoCs containing dozens to hundreds of computation cores. In particular, applications in the area of oil and natural gas exploration are also characterized by the high processing capacity required and would benefit greatly from these high performance systems. This work intends to evaluate a traditional and complex application of the oil and gas industry known as reservoir simulation, developing a solution with integrated computational systems in a single chip, with hundreds of functional unities. For this, as the STORM (MPSoC Directory-Based Platform) platform already has a shared memory model, a new distributed memory model were developed. Also a message passing library has been developed folowing MPI standard / O constante aumento da complexidade das aplica??es demanda um suporte de hardware computacionalmente mais poderoso. Com a aproxima??o do limite de velocidade dos processadores, a solu??o mais vi?vel ? o paralelismo. Baseado nisso e na crescente capacidade de integra??o de transistores em um ?nico chip surgiram os chamados MPSoCs (Multiprocessor System-on-Chip) que dever?o ser, em um futuro pr?ximo, uma alternativa mais r?pida e mais barata aos supercomputadores e clusters. Aplica??es tidas como destinadas exclusivamente a execu??o nesses sistemas de alto desempenho dever?o migrar para m?quinas equipadas com MPSoCs dotados de dezenas a centenas de n?cleos computacionais. Aplica??es na ?rea de explora??o de petr?leo e g?s natural tamb?m se caracterizam pela enorme capacidade de processamento requerida e dever?o se beneficiar desses novos sistemas de alto desempenho. Esse trabalho apresenta uma avalia??o de uma tradicional e complexa aplica??o da ind?stria de petr?leo e g?s natural, a simula??o de reservat?rios, sob a nova ?tica do desenvolvimento de sistemas computacionais integrados em um ?nico chip, dotados de dezenas a centenas de unidades funcionais. Para isso, um modelo de mem?ria distribu?da foi desenvolvido para a plataforma STORM (MPSoC Directory-Based Platform), que j? contava com um modelo de mem?ria compartilhada. Foi desenvolvida, ainda, uma biblioteca de troca de mensagens para esse modelo de mem?ria seguindo o padr?o MPI

Made available in DSpace on 2014-12-17T14:08:34Z (GMT). No. of bitstreams: 1 AntonioRGpdf.pdf: 5141308 bytes, checksum: d76799635535d71b79841802f1a64db0 (MD5) Previous issue date: 2009-07-30 / Petr?leo Brasileiro SA - PETROBRAS / Exploration of heavy oil reservoirs is increasing every year in worldwide, because the discovery of light oil reservoirs is becoming increasingly rare. This fact has stimulated the research with the purpose of becoming viable, technically and economically, the exploration of such oil reserves. In Brazil, in special in the Northeast region, there is a large amount of heavy oil reservoir, where the recovery by the so called secondary methods Water injection or gas injection is inefficient or even impracticable in some reservoirs with high viscosity oils (heavy oils). In this scenario, steam injection appears as an interesting alternative for recover of these kinds of oil reservoirs. Its main mechanism consists of oil viscosity reduction through steam injection, increasing reservoir temperature. This work presents a parametric simulation study of some operational and reservoir variables that had influence on oil recovery in thin reservoirs typically found in Brazilian Northeast Basins, that use the steam injection as improved oil recovery method. To carry out simulations, it was used the commercial software STARS (Steam, Thermal, and Advanced Processes Reservoir Simulator) from CMG (Computer Modeling Group) version 2007.11. Reservoirs variables studied were horizontal permeability, vertical and horizontal permeability ratio, water zone and pay zone thickness ratio, pay zone thickness and thermal conductivity of the rock. Whereas, operational parameters studied were distance between wells and steam injection rate. Results showed that reservoir variables that had more influence on oil recovery were horizontal permeability and water zone and pay zone thickness ratio. In relation to operational variables, results showed that short distances between wells and low steam injection rates improved oil recovery / A cada ano tem ocorrido cada vez mais a explora??o de reservas de ?leo pesado em diversas regi?es do mundo. Isto tem sido feito porque ? cada vez mais rara a exist?ncia de jazidas petrol?feras de ?leos leves. Este fato tem impulsionado in?meras pesquisas em dire??o a tornar vi?vel, do ponto de vista operacional e econ?mico, a explora??o de tais reservas de ?leo. No Brasil, em especial na regi?o Nordeste, existe uma grande quantidade de reservat?rios de ?leos pesados, onde a recupera??o pelos m?todos ditos secund?rios inje??o de ?gua e gases mostram-se ineficientes ou at? invi?veis em alguns reservat?rios que apresentam ?leos de elevada viscosidade. Neste cen?rio, a inje??o de vapor surge como uma alternativa bastante interessante na recupera??o do ?leo desses tipos de reservat?rios. Seu principal mecanismo consiste na redu??o da viscosidade do ?leo por meio da inje??o de um fluido aquecido, no caso, vapor de ?gua, aumentando a temperatura do reservat?rio. Este trabalho apresenta um estudo param?trico das vari?veis de reservat?rio e operacionais que influenciam no fator de recupera??o de ?leo ao longo da vida produtiva do reservat?rio em reservat?rios delgados tipicamente encontrados em Bacias do Nordeste brasileiro, que utilizam a inje??o de vapor como m?todo avan?ado de recupera??o. O estudo foi conduzido atrav?s de simula??o num?rica, utilizando o programa STARS (Steam, Thermal, and Advanced Processes Reservoir Simulator) do grupo CMG (Computer Modelling Group) vers?o 2007.11. As vari?veis de reservat?rio compreenderam a permeabilidade horizontal, a raz?o entre a permeabilidade vertical e horizontal, a raz?o entre a zona de ?gua e a de ?leo, a espessura da zona produtora de ?leo e a condutividade t?rmica da rocha. Enquanto que os par?metros operacionais estudados foram a dist?ncia entre po?os e a vaz?o de inje??o de vapor. Os resultados obtidos mostraram que as vari?veis de reservat?rios que mais influenciaram no fator de recupera??o foram a permeabilidade horizontal e a raz?o entre a zona de ?gua e de ?leo. Com rela??o ?s vari?veis operacionais, menores dist?ncias entre po?os e vaz?es de inje??o melhoram o fator de recupera??o durante a vida produtiva do reservat?rio

Made available in DSpace on 2014-12-17T14:08:35Z (GMT). No. of bitstreams: 1 KeilaRSpdf.pdf: 4445609 bytes, checksum: 3395044458045d549e1940f35912e4a6 (MD5) Previous issue date: 2009-07-31 / Petr?leo Brasileiro SA - PETROBRAS / Due to reservoirs complexity and significantly large reserves, heavy oil recovery has become one of the major oil industry challenges. Thus, thermal methods have been widely used as a strategic method to improve heavy oil recovery. These methods improve oil displacement through viscosity reduction, enabling oil production in fields which are not considered commercial by conventional recovery methods. Among the thermal processes, steam flooding is the most used today. One consequence in this process is gravity segregation, given by difference between reservoir and injected fluids density. This phenomenon may be influenced by the presence of reservoir heterogeneities. Since most of the studies are carried out in homogeneous reservoirs, more detailed studies of heterogeneities effects in the reservoirs during steam flooding are necessary, since most oil reservoirs are heterogeneous. This paper presents a study of reservoir heterogeneities and their influence in gravity segregation during steam flooding process. In this study some heterogeneous reservoirs with physical characteristics similar those found in the Brazilian Northeast Basin were analyzed. To carry out the simulations, it was used the commercial simulator STARS by CMG (Computer Modeling Group) - version 2007.11. Heterogeneities were modeled with lower permeability layers. Results showed that the presence of low permeability barriers can improve the oil recovery, and reduce the effects of gravity segregation, depending on the location of heterogeneities. The presence of these barriers have also increased the recovered fraction even with the reduction of injected steam rate / Devido a complexidade dos reservat?rios e as reservas significativamente grandes, a recupera??o de ?leos pesados tem se tornado um dos grandes desafios da ind?stria petrol?fera. Os processos de recupera??o t?rmica t?m sido largamente empregados como um m?todo estrat?gico para melhorar a recupera??o de ?leo pesado. Estes melhoram o escoamento de ?leos atrav?s da redu??o da viscosidade, viabilizando a produ??o de petr?leo em campos considerados n?o comerciais pelos m?todos convencionais de recupera??o. Entre os m?todos t?rmicos, a inje??o de vapor ? o mais utilizado atualmente. Uma consequ?ncia inerente a este processo ? a segrega??o gravitacional, dada pela diferen?a de densidades dos fluidos do reservat?rio e o injetado. Este fen?meno ? fortemente influenciado pela presen?a de heterogeneidades. Como a maior parte dos estudos ? realizada em reservat?rios homog?neos, necessita-se de um estudo mais detalhado dos efeitos das heterogeneidades nos reservat?rios durante a inje??o de vapor, j? que a maioria dos reservat?rios de petr?leo s?o heterog?neos. Este trabalho apresenta um estudo da influ?ncia da presen?a de heterogeneidades na segrega??o gravitacional durante o processo de inje??o cont?nua de vapor. Os modelos estudados representam reservat?rios heterog?neos com caracter?sticas similares ?s encontradas no Nordeste brasileiro. Para a realiza??o das simula??es, foi utilizado o simulador comercial STARS (Steam, Thermal, and Advanced Processes Reservoir Simulator) do grupo CMG (Computer Modelling Group) vers?o 2007.11. As heterogeneidades foram modeladas como camadas de baixa permeabilidade. Os resultados mostraram que a presen?a de barreiras de baixa permeabilidade pode melhorar a recupera??o de ?leo, al?m de reduzir os efeitos da segrega??o gravitacional, dependendo da localiza??o da heterogeneidade. A presen?a dessas barreiras tamb?m permitiu o aumento da fra??o recuperada mesmo com a redu??o da vaz?o de inje??o do vapor

Made available in DSpace on 2014-12-17T14:08:37Z (GMT). No. of bitstreams: 1 ErnestoVBa_DISSERT.pdf: 9825397 bytes, checksum: 732b67b111fb317d406c771240e47d87 (MD5) Previous issue date: 2009-12-18 / Electrical resistive heating (ERH) is a thermal method used to improve oil recovery. It can increase oil rate and oil recovery due to temperature increase caused by electrical current passage through oil zone. ERH has some advantage compared with well-known thermal methods such as continuous steam flood, presenting low-water production. This method can be applied to reservoirs with different characteristics and initial reservoir conditions. Commercial software was used to test several cases using a semi-synthetic homogeneous reservoir with some characteristics as found in northeast Brazilian basins. It was realized a sensitivity analysis of some reservoir parameters, such as: oil zone, aquifer presence, gas cap presence and oil saturation on oil recovery and energy consumption. Then it was tested several cases studying the electrical variables considered more important in the process, such as: voltage, electrical configurations and electrodes positions. Energy optimization by electrodes voltage levels changes and electrical settings modify the intensity and the electrical current distribution in oil zone and, consequently, their influences in reservoir temperature reached at some regions. Results show which reservoir parameters were significant in order to improve oil recovery and energy requirement in for each reservoir. Most significant parameters on oil recovery and electrical energy delivered were oil thickness, presence of aquifer, presence of gas cap, voltage, electrical configuration and electrodes positions. Factors such as: connate water, water salinity and relative permeability to water at irreducible oil saturation had low influence on oil recovery but had some influence in energy requirements. It was possible to optimize energy consumption and oil recovery by electrical variables. Energy requirements can decrease by changing electrodes voltages during the process. This application can be extended to heavy oil reservoirs of high depth, such as offshore fields, where nowadays it is not applicable any conventional thermal process such as steam flooding / O Aquecimento El?trico Resistivo (AER) ? um m?todo t?rmico usado para aumentar a recupera??o de petr?leo. Este aumenta a vaz?o de ?leo e conseq?entemente a recupera??o de petr?leo devido ao aumento de temperatura promovida pela passagem de corrente el?trica na zona de interesse. O AER tem algumas vantagens sobre m?todos t?rmicos conhecidos, como inje??o cont?nua de vapor, por apresentar baixa produ??o de ?gua, podendo ser aplicado a reservat?rios com diversas caracter?sticas e diversas condi??es iniciais. Um software comercial foi usado para testar v?rios casos usando um reservat?rio homog?neo semi-sint?tico com algumas caracter?sticas encontradas em reservat?rio da bacia sedimentar do Nordeste Brasileiro. Foi realizada uma an?lise de sensibilidade dos par?metros de reservat?rio, tais como: espessura da zona de ?leo, presen?as de capa de g?s e de aq??fero e satura??o de ?leo, na recupera??o de ?leo e consumo de energia el?trica. V?rios casos foram testados usando vari?veis el?tricas consideradas mais importantes no processo, tais como: tens?o, configura??es el?tricas e posi??es dos eletrodos. Os resultados mostram que os par?metros de reservat?rio foram significativos no sentido de aumentar a recupera??o de ?leo e a demanda de energia em cada reservat?rio. Os par?metros mais significativos na recupera??o de ?leo e no consumo de energia foram: a espessura da zona de ?leo, presen?as de capa de g?s e de aq??fero, as configura??es el?tricas e a posi??o dos eletrodos. Fatores como: satura??o irredut?vel de ?gua, salinidade da ?gua e a permeabilidade relativa da ?gua na satura??o residual de ?leo tiveram pouca influ?ncia na recupera??o de ?leo, mas tiveram uma influ?ncia maior na demanda de energia. Foi poss?vel otimizar o consumo de energia com a recupera??o de ?leo usando as vari?veis el?tricas. Estas aplica??es podem ser estendidas para reservat?rios de ?leo pesado e de grande profundidade, como em campos mar?timos (offshore), onde atualmente n?o ? poss?vel o uso de m?todos t?rmicos convencionais de recupera??o, como a inje??o de vapor

Made available in DSpace on 2014-12-17T14:08:41Z (GMT). No. of bitstreams: 1 EduardoEFB_DISSERT_1-100.pdf: 2141096 bytes, checksum: 2c8315a9a7567e27a669088e0bbc6350 (MD5) Previous issue date: 2008-12-01 / The application of thermal methods, to increase the recovery of heavy oil in mature fields through drainage with multilateral and horizontal wells, has been thoroughly studied, theorically, experimentally, testing new tools and methods. The continuous injection of steam, through a steam injector well and a horizontal producer well in order to improve horizontal sweep of the fluid reservoir, it is an efficient method. Starting from an heterogeneous model, geologically characterized, modeling geostatistics, set history and identification of the best path of permeability, with seismic 3D, has been dubbed a studying model. It was studied horizontal wells in various directions in relation to the steam and the channel of higher permeability, in eight different depths. Into in the same area were studied, the sensitivity of the trajectories of horizontal wells, according to the depth of navigation. With the purpose of obtaining the highest output of oil to a particular flow, quality, temperature and time for the injection of steam. The wells studied showed a significant improvement in the cumulative oil recovery in one of the paths by promoting an alternative to application in mature fields or under development fields with heavy oil / A aplica??o de m?todos t?rmicos, para aumentar a recupera??o de ?leo pesado em campos maduros atrav?s da drenagem com po?os horizontais e multilaterais, tem sido exaustivamente estudada, te?rica e experimentalmente, testando novas ferramentas e novos m?todos. A inje??o cont?nua de vapor, atrav?s de um po?o injetor e de um po?o horizontal produtor com o objetivo de proporcionar uma varredura dos fluidos do reservat?rio, mostra-se um m?todo eficiente. Partindo de um modelo heterog?neo, geologicamente caracterizado por, modelagem geoestat?stica, ajuste de hist?rico e identifica??o do melhor caminho de permeabilidade, com a s?smica 3D, foi montado um modelo para estudo. Foram estudados po?os horizontais em v?rias dire??es em rela??o ao injetor de vapor e ao canal de maior permeabilidade, em oito profundidades diferentes. Dentro de uma mesma zona foram estudadas, a sensibilidade das trajet?rias de po?os horizontais, em fun??o da profundidade de navega??o. Com a finalidade de obter a maior produ??o acumulada de ?leo a uma determinada vaz?o, qualidade, temperatura e per?odo de inje??o do vapor. Os po?os estudados evidenciam uma melhora significativa na recupera??o acumulada de ?leo em uma das trajet?rias, promovendo uma alternativa de aplica??o em campos maduros ou em desenvolvimento com ?leo pesado

Submitted by Automa??o e Estat?stica (sst@bczm.ufrn.br) on 2016-06-06T21:01:05Z No. of bitstreams: 1 GabrielPabloNudelman_DISSERT.pdf: 4667154 bytes, checksum: 87376721e94f9b7485cbec0fb6ad20a8 (MD5) / Approved for entry into archive by Arlan Eloi Leite Silva (eloihistoriador@yahoo.com.br) on 2016-06-08T20:53:05Z (GMT) No. of bitstreams: 1 GabrielPabloNudelman_DISSERT.pdf: 4667154 bytes, checksum: 87376721e94f9b7485cbec0fb6ad20a8 (MD5) / Made available in DSpace on 2016-06-08T20:53:05Z (GMT). No. of bitstreams: 1 GabrielPabloNudelman_DISSERT.pdf: 4667154 bytes, checksum: 87376721e94f9b7485cbec0fb6ad20a8 (MD5) Previous issue date: 2015-09-29 / Nos ?ltimos dezesseis anos surgiu no Brasil um segmento de produtores independentes com foco de atua??o nas bacias terrestres e de ?guas rasas. Entre os desafios destas empresas se encontra o desenvolvimento de campos com projetos com um valor presente l?quido (VPL) baixo. O objetivo deste trabalho foi estudar a melhor op??o t?cnico-econ?mica de desenvolvimento de um campo de petr?leo no Nordeste Brasileiro aplicando a simula??o de reservat?rios. A partir de dados reais de geologia, reservat?rios e produ??o foi realizado o modelo geol?gico e de simula??o. Devido a n?o ter an?lise PVT, foram utilizados os dados do ensaio de destila??o denominado Pontos de Ebuli??o Verdadeiros (PEV) para criar um modelo de fluidos gerando as curvas PVT. Ap?s realizado o ajuste manual do hist?rico, foram simulados quatro cen?rios de desenvolvimento: a extrapola??o de produ??o sem novos investimentos, a convers?o de um po?o produtor para inje??o de g?s imisc?vel, a perfura??o de um po?o vertical e a perfura??o de um po?o horizontal. Como resultados, do ponto de vista financeiro, a inje??o de g?s foi a alternativa com menor valor agregado, podendo ser vi?vel caso haja restri??es ambientais ou regulat?rias de queima ou de ventila??o ao meio ambiente do g?s produzido do campo ou de campos vizinhos. O fator de recupera??o atingido com a perfura??o dos po?os vertical e horizontal ? similar, mas a perfura??o do po?o horizontal ? um projeto de acelera??o de produ??o, portanto a produ??o acumulada incremental atualizada com uma taxa m?nima de atratividade da empresa ? maior. A depender do pre?o do barril de petr?leo Brent e do custo de perfura??o esta op??o pode ser t?cnica e financeiramente vi?vel. / In the last 16 years emerged in Brazil a segment of independent producers with focus on onshore basins and shallow waters. Among the challenges of these companies is the development of fields with projects with a low net present value (NPV). The objective of this work was to study the technical-economical best option to develop an oil field in the Brazilian Northeast using reservoir simulation. Real geology, reservoir and production data was used to build the geological and simulation model. Due to not having PVT analysis, distillation method test data known as the true boiling points (TBP) were used to create a fluids model generating the PVT data. After execution of the history match, four development scenarios were simulated: the extrapolation of production without new investments, the conversion of a producing well for immiscible gas injection, the drilling of a vertical well and the drilling of a horizontal well. As a result, from the financial point of view, the gas injection is the alternative with lower added value, but it may be viable if there are environmental or regulatory restrictions to flaring or venting the produced gas into the atmosphere from this field or neighboring accumulations. The recovery factor achieved with the drilling of vertical and horizontal wells is similar, but the horizontal well is a project of production acceleration; therefore, the present incremental cumulative production with a minimum rate of company's attractiveness is higher. Depending on the crude oil Brent price and the drilling cost, this option can be technically and financially viable.